Búsqueda Imágenes Maps Play YouTube Noticias Gmail Drive Más »
Iniciar sesión
Usuarios de lectores de pantalla: deben hacer clic en este enlace para utilizar el modo de accesibilidad. Este modo tiene las mismas funciones esenciales pero funciona mejor con el lector.

Patentes

  1. Búsqueda avanzada de patentes
Número de publicaciónUS7556715 B2
Tipo de publicaciónConcesión
Número de solicitudUS 10/825,230
Fecha de publicación7 Jul 2009
Fecha de presentación16 Abr 2004
Fecha de prioridad9 Ene 2004
TarifaPagadas
También publicado comoCA2455011A1, CA2455011C, US7914670, US8685210, US20050150816, US20100006474, US20110174592
Número de publicación10825230, 825230, US 7556715 B2, US 7556715B2, US-B2-7556715, US7556715 B2, US7556715B2
InventoresLes Gaston, Donald Norman Madge, William Lester Strand, Ian Noble, William Nicholas Garner, Mike Lam
Cesionario originalSuncor Energy, Inc.
Exportar citaBiBTeX, EndNote, RefMan
Enlaces externos: USPTO, Cesión de USPTO, Espacenet
Bituminous froth inline steam injection processing
US 7556715 B2
Resumen
An inline bitumen froth steam heater system is comprised of steam injection and static mixing devices. The steam heater system heats and de-aerates an input bitumen froth without creating downstream processing problems with the bitumen froth such as emulsification or live steam entrainment. The inline bitumen froth steam heater is a multistage unit that injects and thoroughly mixes the steam with bitumen resulting in an output bitumen material having a homogenous temperature of about 190° F. The heating system conditions a superheated steam supply to obtain saturated steam at about 300° F. The saturated steam is contacted with a bitumen froth flow and mixed in a static mixer stage. The static mixers provide a surface area and rotating action that allows the injected steam to condense and transfer its heat to the bitumen froth. The mixing action and the increase in temperature of the bitumen froth results in reduction in bitumen viscosity and also allows the release of entrapped air from the bitumen froth.
Imágenes(3)
Previous page
Next page
Reclamaciones(22)
1. Apparatus for heating a bitumen froth by steam, the apparatus comprising:
an injector body comprising a bitumen froth inlet for receiving the bitumen froth, a steam inlet for receiving the steam, and an injector outlet; and
a static mixer body having first and second spaced ends and forming an enclosed passageway extending between the first and second ends, wherein the first end is in communication with the injector outlet, the static mixer body supporting a plurality of baffles disposed within the enclosed passageway to effect a mixing action of the bitumen froth and the steam flowing through the enclosed passageway thereof to form a heated feed;
wherein the steam inlet is disposed to inject the steam into the injector body towards the enclosed passageway in a direction generally parallel to the a longitudinal axis of the enclosed passageway; and
wherein the apparatus is operably configured to: (a) force the bitumen froth and the steam through the injector outlet into the enclosed passageway, (b) force the bitumen froth and the steam through the enclosed passageway from the first end to the second end so as to cause the steam to contact the bitumen froth so as to form the heated feed, and (c) force all of the heated feed to exit through the second end of the static mixer body, including when the enclosed passageway is disposed parallel or about parallel to the horizontal axis.
2. The apparatus of claim 1 wherein the baffles are disposed within the static mixer body to impart a lateral, radial, tangential or circumferential directional component to the bitumen froth and the steam, the directional component changing repeatedly along a length of the enclosed passageway.
3. The apparatus of claim 1 further comprising a steam flow control valve to control a rate of supplying the steam to the steam inlet from a steam source.
4. The apparatus of claim 3 further comprising a first temperature transmitter disposed to measure a temperature of the heated feed exiting the enclosed passageway of the static mixer, wherein steam flow control valve is responsive to the measured temperature of the heated feed.
5. The apparatus of claim 1 further comprising a steam flow pressure control valve to control a pressure of the steam supplied to the steam inlet from a steam source.
6. The apparatus of claim 5 further comprising a pressure transmitter disposed to measure the pressure of the steam supplied from the steam flow pressure control valve, wherein the steam flow pressure control valve is operative to maintain the steam supplied to the steam inlet at a predetermined pressure in response to the measured pressure of the steam supplied from the steam flow pressure control valve.
7. The apparatus of claim 1 further comprising:
a condensate source and a steam source;
a condensate mixer operably configured to mix a condensate from the condensate source with the steam from the steam source for modulating a temperature of the steam supplied to the steam inlet; and
a condensate flow control valve to control a supply of the condensate to the condensate mixer.
8. The apparatus of claim 7 further comprising a second temperature transmitter disposed to measure the temperature of the steam supplied to the steam inlet and relay a representation of the measured temperature of the steam to the condensate flow control valve, wherein the condensate flow control valve is operative to control the supply of the condensate to the steam supplied to the steam inlet.
9. The apparatus of claim 1 wherein the steam supplied to the steam inlet comprises saturated steam.
10. The apparatus of claim 9 wherein the steam supplied to the steam inlet has a temperature of about 300° F. and a pressure of about 90 psi.
11. The apparatus of claim 9 wherein the heated feed has a substantially uniform temperature.
12. The apparatus of claim 11 wherein the substantially uniform temperature is about 190° F.
13. Apparatus for heating a bitumen froth by steam, the apparatus comprising:
an injector body comprising walls defining a chamber of the injector body, a first injector inlet for introducing the bitumen froth having a bitumen froth flow into the chamber, a second injector inlet for introducing the steam having a steam flow into the chamber, and an injector outlet, wherein the second injector inlet is configured for introducing steam; and
a static mixer body comprising:
a mixer inlet and a mixer outlet, the static mixer body forming an enclosed passageway extending between the mixer inlet and the mixer outlet, the mixer inlet being in fluid communication with the injector outlet for receiving the bitumen froth and the steam; and
mixing means for mixing the bitumen froth and the steam flowing through the enclosed passageway of the static mixer body to form a heated feed;
wherein the injector body and the static mixer body are operably configured to: (a) force the bitumen froth and the steam through the enclosed passageway from the mixer inlet to the mixer outlet so as to cause the steam to contact the bitumen froth and form the heated feed, and (b) force all of the heated feed to exit through the mixer outlet, including when the enclosed passageway is disposed parallel or about parallel to the horizontal axis.
14. The apparatus of claim 13 wherein the mixing means impart a lateral, radial, tangential or circumferential directional component to the bitumen froth and the steam, the directional component changing repeatedly along a length of the enclosed passageway.
15. The apparatus of claim 13 wherein the mixing means comprises a plurality of static mixer barriers forming partial walls disposed within the enclosed passageway.
16. The apparatus of claim 15 wherein the steam injected by the second injector inlet has a temperature of about 300° F. to about 500° F. and a pressure of about 90 to 150 psi.
17. The apparatus of claim 15 wherein the heated feed produced by the static mixer body has a temperature of about 190° F.
18. The apparatus of claim 13 further comprising a steam flow control valve to control a rate of the steam flow into the chamber and a first temperature transmitter disposed to measure a temperature of the heated feed exiting the static mixer body, wherein the injector body, the static mixer body, the steam flow control valve and the first temperature transmitter form a first closed loop control system, the steam flow control valve being responsive to the measured temperature of the heated feed by the first temperature transmitter.
19. The apparatus of claim 18 further comprising a steam flow pressure control valve to control a pressure of the steam flow into the chamber and a pressure transmitter disposed to measure the pressure of the steam flow from the pressure control valve, wherein the injector body, the static mixer body, the steam flow control valve, the temperature transmitter, the steam flow pressure control valve and the pressure transmitter form a second closed loop control system, the steam flow pressure control valve being responsive to the measured pressure.
20. The apparatus of claim 19 further comprising a condensate flow control valve to control the supply of a condensate to the steam for modulating the temperature of the steam for injecting by the second injector inlet and a second temperature transmitter disposed to measure the temperature of the steam supplied to the second injector inlet, wherein the injector body, the static mixer body, the steam flow control valve, the first temperature transmitter, the steam flow pressure control valve, the pressure transmitter, the condensate flow control valve, and the second temperature transmitter form a third closed loop control system, the condensate flow control valve being responsive to the temperature of the steam measured by the second temperature transmitter.
21. The apparatus of claim 13 wherein the mixing means comprises a baffle disposed across the enclosed passageway.
22. The apparatus of claim 13 wherein the steam supplied to the second injector inlet comprises saturated steam.
Descripción
FIELD OF THE INVENTION

This invention relates to bitumen processing and more particularly is related to heating bituminous froth using inline steam injection.

BACKGROUND TO THE INVENTION

In extracting bitumen hydrocarbons from tar sands, one extraction process separates bitumen from the sand ore in which it is found using an ore washing process generally referred to as the Clark hot water flotation method. In this process, a bitumen froth is typically recovered at about 150° F. and contains residual air from the flotation process. Consequently, the froth produced from the Clark hot water flotation method is usually described as aerated bitumen froth. Aerated bitumen froth at 150° F. is difficult to work with. It has similar properties to roofing tar. It is very viscous and does not readily accept heat. Traditionally, processing of aerated bitumen froth requires the froth to be heated to 190° to 200° F. and deaerated before it can move to the next stage of the process.

Heretofore, the aerated bitumen froth is heated and de-aerated in large atmospheric tanks with the bitumen fed in near the top of the vessel and discharged onto a shed deck. The steam is injected below the shed deck and migrates upward, transferring heat and stripping air from the bitumen as they contact. The method works but much of the steam is wasted and bitumen droplets are often carried by the exiting steam and deposited on nearby vehicles, facilities and equipment.

SUMMARY OF THE INVENTION

The invention provides an inline steam heater to supply heated steam to a bitumen froth by direct contact of the steam to the bitumen froth resulting in superior in efficiency and environmental friendliness than processes heretofore employed.

In one of its aspect, the invention provides an inline bitumen froth steam heater system including at least one steam injection stage, each steam injection stage followed by a mixing stage. Preferably, the mixing stage obtains a mixing action using static mixing devices, for example, using baffle partitions in a pipe. In operation, the invention heats the bitumen froth and facilitates froth deaeration by elevating the froth temperature. In operation the bitumen froth heating is preferably obtained without creating downstream problems such as emulsification or live steam entrainment. The froth heater is a multistage unit that injects and thoroughly mixes the steam with bitumen resulting in solution at homogenous temperature. Steam heated to 300 degrees Fahrenheit is injected directly into a bitumen froth flowing in a pipeline where initial contact takes place. The two incompatible substances are then forced through a series of static mixers, causing the steam to contact the froth. The mixer surface area and rotating action of the material flowing through the static mixer breaks the components up into smaller particles, increasing contact area and allowing the steam to condense and transfer its heat to the froth. The reduction in bitumen viscosity also allows the release of entrapped air.

Other objects, features and advantages of the present invention will be apparent from the accompanying drawings, and from the detailed description that follows below. As will be appreciated, the invention is capable of other and different embodiments, and its several details are capable of modifications in various respects, all without departing from the invention. Accordingly, the drawings and description of the preferred embodiments are illustrative in nature and not restrictive

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a functional block diagram of a preferred embodiment of a bitumen froth heating process arrangement of the invention.

FIG. 2 is a cross section elevation view of an inline steam heater and mixer stage of FIG. 1.

FIG. 2 a is an elevation view of a baffle plate of FIG. 2.

DETAILED DESCRIPTION OF THE INVENTION

In accordance with a preferred embodiment of the process two inputs components, namely, bitumen froth and steam, are contacted to produce an output homogenous bitumen product heated to a temperature of 190° F. The input bitumen froth component 10 is supplied at about 150° F. In a pilot plant implementation the input bitumen froth component is supplied via a 28 inch pipeline at a rate of about 10,000 barrels per hour. The input steam component 12 is supplied as a superheated steam at about 500° F. and at 150 psi.

FIG. 1 shows a functional block diagram of a preferred embodiment of a bitumen froth heating apparatus arranged in accordance with the invention. The input steam component 12 is supplied to a pressure control valve 14 which reduces the pressure to a set point pressure, which is typically about 90 psi. A pressure transmitter 16 is provided to monitor the pressure of the steam downstream from the pressure control valve 14 to provide a closed loop control mechanism to control the pressure of the steam at the set point pressure. The pressure controlled steam is supplied to a temperature control valve 18 that is used to control the supply of condensate 20 to cool the steam to its saturation point, which is about 300° F. at the controlled pressure of 90 psi. A temperature sensor 22 monitors the steam temperature downstream from the temperature control valve to provide a closed loop control mechanism to control the temperature of the steam at the temperature set point setting.

The optimum parameters for steam injection vary so a computer 24 executes a compensation program to review the instantaneously supplied instrumentation pressure 26 and temperature 28 measurements and adjusts inlet steam pressure and temperature set point settings as required. A pressure sensor 29 measures the pressure of the input bitumen component 10 to provide the compensation program executing on computer 24 with this parameter to facilitate optimum control of the parameters for steam injection.

To provide a greater capacity for supply or transfer of heat to the bitumen froth component, the pressure and temperature controlled steam 30 is split into two steam sub-streams 30 a, 30 b. Each steam sub-stream is supplied to a respective steam injector 32 a, 32 b and the steam injectors 32 a and 32 b are arranged in series to supply heat to the bitumen froth component stream 10. While two steam injectors arranged in series are shown in the figure, it will be understood that the bitumen froth component stream 10 could equally well be split into two sub-streams and each bitumen froth component sub-stream supplied to a respective steam injector arranged in parallel. Moreover, it will be understood that more than two sub-streams of either the steam component or the bitumen component streams could be provided if process flow rates require. A suitable inline steam injector 32 a, 32 b is manufactured by Komax Systems Inc. located in Calif., USA.

An inline steam injection heater works well in heating water compatible fluids but bitumen is not water compatible so additional mixing is advantageous to achieve uniform fluid temperature. Consequently, in the preferred embodiment depicted in FIG. 1, the bitumen and steam material flow mixture is passed through an inlet baffle 34 a, 34 b downstream from the respective steam injector 32 a, 32 b. The inlet baffle, which is shown more clearly in FIG. 2 a, directs the material flow mixture downward to initiate the mixing action of the steam component with the bitumen froth component. Mixing of the material flow continues by passing the material flow through static mixers 36 a and 36 b respectively.

As seen most clearly in FIG. 2, the static mixers provide baffles 40 arranged along the interior volume of each static mixer to effect a mixing action of the material flowing through the static mixer. The mixing action of the material flow through the static mixer is provided by arranging the baffles 40 within the static mixer to impart a lateral, radial, tangential and/or circumferential directional component to the material flow that changes repeatedly along the length of the static mixer. Different static mixer designs and baffle arrangements may be used to advantage in mixing the steam component with the bitumen froth component.

A temperature transmitter 42 is located downstream of the mixers 36. The temperature of the material flow exiting the static mixer is measured by the temperature transmitter 42 and is used to control the rate of supply of steam to the inline steam injector 32 by the associated flow control valve 44. In this manner, a closed loop control system is provided to control the supply of the steam component to the bitumen froth component to obtain a set point or target output temperature of the material flow leaving the static mixer 36.

Referring again to FIG. 1, the heating system shown in FIG. 2 is arranged with a temperature transmitter 42 a, 42 b located downstream of each respective mixer 36 a, 36 b. The temperature of the material exiting each static mixer is measured by the temperature transmitter and is used to control the rate of supply of steam to the inline steam injectors 32 a, 32 b by the associated flow control valve 44 a, 44 b respectively. In this manner, a closed loop control system is provided to control the supply of the steam component to the bitumen froth component to obtain a set point or target output temperature of the material flow leaving each static mixer stage 36 a, 36 b. The water content of the bitumen froth component 10 can range form 30% to 50%. In a pilot plant implementation of the preferred embodiment, each inline steam heater 32 a, 32 b was found to be capable of heating about 10,000 barrels per hour of bitumen froth by about 30° F. utilizing about 80,000 pounds per hour of steam. By way of comparison to conventional process apparatus, the atmospheric tank method would use about 125,000 pounds of steam to achieve a similar heat transfer.

After heating, the heated bitumen froth is delivered to a plant for processing. To facilitate material flow rate co-ordination with the processing plant, the heated bitumen froth may be discharged to a downstream holding tank 46, preferably above the liquid level 48. The heated, mixed bitumen froth releases entrained air, preferably, therefore, the holding tank is provided with a vent 50 to disperse the entrapped air released from the bitumen froth. To maintain the temperature of the heated bitumen froth in the holding tank 46, a pump 50 and recycle line 52 are provided, which operate to recycle the hot bitumen froth from the holding tank to the process inlet of the heaters.

The invention has been described with reference to preferred embodiments. Those skilled in the art will perceive improvements, changes, and modifications. The scope of the invention including such improvements, changes and modifications is defined by the appended claims.

Citas de patentes
Patente citada Fecha de presentación Fecha de publicación Solicitante Título
US68589529 Ago 19005 Nov 1901Ernst WirthProcess of purifying anthracene.
US159015627 Mar 192422 Jun 1926Ellis Foster CoProcess of treating wood tar oil
US159897327 Nov 19257 Sep 1926Kolsky GeorgeArt of treating oils
US205288118 May 19351 Sep 1936Calco Chemical Co IncPurification of alcohols
US223679613 Sep 19381 Abr 1941Kipper Herman BProcess for the synthesis of chlorinated saturated and unsaturated hydrocarbon oils
US273401922 Abr 19537 Feb 1956 Hydrofining naphthenic lubricating oil
US284735330 Dic 195512 Ago 1958Texas CoTreatment of residual asphaltic oils with light hydrocarbons
US291042419 Nov 195627 Oct 1959Phillips Petroleum CoSeparation and recovery of oil from oil sands
US292102314 May 195712 Ene 1960Pure Oil CoRemoval of naphthenic acids by hydrogenation with a molybdenum oxidesilica alumina catalyst
US3159562 *7 Sep 19611 Dic 1964Exxon Research Engineering CoIntegrated process for effectively recovering oil from tar sands
US3509641 *17 May 19685 May 1970Great Canadian Oil SandsTar sands conditioning vessel
US359420129 Abr 196820 Jul 1971Shell Oil CoAsphalt emulsions
US361753012 Nov 19692 Nov 1971Atlantic Richfield CoMetals removal from heavy hydrocarbon fractions
US379815710 May 197319 Mar 1974Mexicano Inst PetrolProcess for the removal of contaminants from hydrocracking feedstocks
US38070906 Dic 197230 Abr 1974Exxon Research Engineering CoPurifications of fuels
US38081209 Jul 197330 Abr 1974Atlantic Richfield CoTar sands bitumen froth treatment
US387653227 Feb 19738 Abr 1975Gulf Research Development CoMethod for reducing the total acid number of a middle distillate oil
US389390710 Sep 19738 Jul 1975Exxon Research Engineering CoMethod and apparatus for the treatment of tar sand froth
US396777727 Nov 19746 Jul 1976Exxon Research And Engineering CompanyApparatus for the treatment of tar sand froth
US39717189 Jul 197427 Jul 1976Elast-O-Cor Products & Engineering LimitedHydrocyclone separator or classifier
US3998702 *14 Oct 197521 Dic 1976Great Canadian Oil Sands LimitedApparatus for processing bituminous froth
US4033853 *16 Ene 19765 Jul 1977Great Canadian Oil Sands LimitedProcess and apparatus for heating and deaerating raw bituminous froth
US403528220 Ago 197512 Jul 1977Shell Canada LimitedProcess for recovery of bitumen from a bituminous froth
US407260910 Feb 19777 Feb 1978Her Majesty The Queen In Right Of Canada, As Represented By The Minister Of Energy, Mines And ResourcesCapacitance system for heavy phase discharge of second stage centrifugal separation circuit
US410133323 May 197718 Jul 1978Joy Manufacturing CompanySlurry of mill tailings and water
US41168092 Dic 197626 Sep 1978Her Majesty The Queen In Right Of Canada, As Represented By The Minister Of Energy, Mines And ResourcesDeaerator circuit for bitumen froth
US412077629 Ago 197717 Oct 1978University Of UtahComminution, digestion, displacement
US417202511 May 197823 Oct 1979Petro-Canada Exploration Inc.Process for secondary recovery of bitumen in hot water extraction of tar sand
US427974315 Nov 197921 Jul 1981University Of UtahAir-sparged hydrocyclone and method
US43057336 Mar 198015 Dic 1981Linde AgMethod of treating natural gas to obtain a methane rich fuel gas
US43371432 Jun 198029 Jun 1982University Of UtahProcess for obtaining products from tar sand
US438391418 May 198117 May 1983Petro-Canada Exploration Inc.Dilution centrifuging of bitumen froth from the hot water process for tar sand
US439774120 Nov 19819 Ago 1983University Of UtahApparatus and method for separating particles from a fluid suspension
US439902729 Ago 198016 Ago 1983University Of Utah Research FoundationFlotation apparatus and method for achieving flotation in a centrifugal field
US439911221 Abr 198116 Ago 1983Societe Nationale Elf AquitaineProcess for the catalytic incineration of residual gases containing a low content of at least one sulfur compound selected from COS, CS2 and the mercaptans and possibility at least one member of the group
US44090901 Feb 198211 Oct 1983University Of UtahProcess for recovering products from tar sand
US44104176 Oct 198018 Oct 1983University Of Utah Research FoundationProcess for separating high viscosity bitumen from tar sands
US4424113 *7 Jul 19833 Ene 1984Mobil Oil CorporationRecovering bitumens
US443799823 Abr 198220 Mar 1984Suncor, Inc.Method for treating oil sands extraction plant tailings
US446289217 Mar 198331 Jul 1984Petro-Canada Exploration Inc.Control of process aid used in hot water process for extraction of bitumen from tar sand
US447089914 Feb 198311 Sep 1984University Of UtahBitumen recovery from tar sands
US448629417 Oct 19834 Dic 1984University Of UtahProcess for separating high viscosity bitumen from tar sands
US450295031 Ene 19845 Mar 1985Nippon Oil Co., Ltd.Process for the solvent deasphalting of asphaltene-containing hydrocarbons
US451428730 Dic 198230 Abr 1985Nippon Oil Co., Ltd.Process for the solvent deasphalting of asphaltene-containing hydrocarbons
US45143051 Dic 198230 Abr 1985Petro-Canada Exploration, Inc.Azeotropic dehydration process for treating bituminous froth
US452515511 Abr 198425 Jun 1985Alfa-Laval Marine And Powering Engineering AbCentrifugal separator and method of operating the same
US45252693 May 198425 Jun 1985Nippon Oil Co., Ltd.Mixing with metal compound and solvent
US452810031 Oct 19839 Jul 1985General Electric CompanyProcess for producing high yield of gas turbine fuel from residual oil
US45320243 Dic 198430 Jul 1985The Dow Chemical CompanyProcess for recovery of solvent from tar sand bitumen
US454589215 Abr 19858 Oct 1985Alberta Energy Company Ltd.Treatment of primary tailings and middlings from the hot water extraction process for recovering bitumen from tar sand
US458114211 Ene 19848 Abr 1986Titech, Joh. H. AndresenHydrocyclone
US458518029 Jun 198429 Abr 1986Alan PottsMineral breakers
US460498819 Mar 198412 Ago 1986Budra Research Ltd.Liquid vortex gas contactor
US463451911 Jun 19856 Ene 1987Chevron Research CompanyProcess for removing naphthenic acids from petroleum distillates
US467707421 Jun 198430 Jun 1987The Lubrizol CorporationProcess for reducing sulfur-containing contaminants in sulfonated hydrocarbons
US473382830 Ene 198729 Mar 1988Mmd Design & Consultancy LimitedMineral breaker
US474489021 Mar 198617 May 1988University Of UtahFor separating particles from suspension such as coal and mineral ore slurries, centrifugal field
US478133115 Oct 19871 Nov 1988Alan PottsMineral breaker
US478326828 Dic 19878 Nov 1988Alberta Energy Company, Ltd.Microbubble flotation process for the separation of bitumen from an oil sands slurry
US479962716 Ene 198724 Ene 1989Mmd Design And Consultancy LimitedMineral sizers
US48283939 Mar 19879 May 1989501 B.V. GrintMethod for obtaining a base material for building mortar
US483843417 May 198813 Jun 1989University Of UtahAir sparged hydrocyclone flotation apparatus and methods for separating particles from a particulate suspension
US485112320 Nov 198625 Jul 1989Tetra Resources, Inc.Separation process for treatment of oily sludge
US48593171 Feb 198822 Ago 1989Shelfantook William EPurification process for bitumen froth
US49158199 Sep 198810 Abr 1990The British Petroleum Compan PlcTreatment of viscous crude oils
US49815792 Dic 19881 Ene 1991The Standard Oil CompanyProcess for separating extractable organic material from compositions comprising said extractable organic material intermixed with solids and water
US499409727 Sep 198919 Feb 1991B. B. Romico B.V. I.O.Rotational particle separator
US50097737 Ene 198723 Abr 1991Alberta Energy Company Ltd.Monitoring surfactant content to control hot water process for tar sand
US501728130 May 198921 May 1991Tar Sands Energy Ltd.Treatment of carbonaceous materials
US503227520 Nov 198716 Jul 1991Conoco Specialty Products Inc.Cyclone separator
US503939819 Mar 199013 Ago 1991UopElimination of caustic prewash in the fixed bed sweetening of high naphthenic acids hydrocarbons
US505520216 Nov 19888 Oct 1991Conoco Specialty Products Inc.Method and apparatus for maintaining predetermined cyclone separation efficiency
US507317715 Oct 199017 Dic 1991B.B. Romico B.V. I.O.Rotational particle separator
US509298330 Nov 19893 Mar 1992The Standard Oil CompanyProcess for separating extractable organic material from compositions comprising said extractable organic material intermixed with solids and water using a solvent mixture
US51184086 Sep 19912 Jun 1992Alberta Energy Company, LimitedReducing the water and solids contents of bitumen froth moving through the launder of a spontaneous flotation vessel
US512400822 Jun 199023 Jun 1992Solv-Ex CorporationMultistep processing in definite sequence; recycling all reactants and reagents; heat recovery
US514359814 Ene 19881 Sep 1992Amoco CorporationMethods of tar sand bitumen recovery
US515675129 Mar 199120 Oct 1992Miller Neal JThree stage centrifuge and method for separating water and solids from petroleum products
US51868204 Dic 199116 Feb 1993University Of AlabamaAgitation and controlled shearing with clean coarse sand in water, then elution and froth flotation, all with cooling
US520780527 Mar 19924 May 1993Emtrol CorporationNarrow slot; air pollution control
US522314812 Nov 199129 Jun 1993Oslo Alberta LimitedProcess for increasing the bitumen content of oil sands froth
US52365772 Mar 199217 Ago 1993Oslo Alberta LimitedProcess for separation of hydrocarbon from tar sands froth
US52425802 Mar 19927 Sep 1993Esso Resources Canada LimitedRecovery of hydrocarbons from hydrocarbon contaminated sludge
US524260410 Ene 19927 Sep 1993Sudden Service Co.Lateral flow coalescing multiphase plate separator
US526411826 Dic 199123 Nov 1993Alberta Energy Company, Ltd.Pipeline conditioning process for mined oil-sand
US529535026 Jun 199222 Mar 1994Texaco Inc.Process for the generation of power
US531666423 Oct 199231 May 1994Canadian Occidental Petroleum, Ltd.Separation of sand from hydrocarbons using chemicals such as nonionic surfactants of ethoxylated alkylphenols and dialkylphenols
US534046724 Oct 199123 Ago 1994Canadian Occidental Petroleum Ltd.From tar sand; slurrying with ethylene oxide alkylphenol adduct, aeration
US548056627 Nov 19912 Ene 1996Bitmin CorporationWith hot water, rolling drum
US553853920 Ene 199523 Jul 1996Wahlco, Inc.Catalytic sulfur trioxide flue gas conditioning
US554075512 Sep 199530 Jul 1996Wahlco, IncCatalytic sulfur trioxide flue gas conditioning
US55818644 May 199510 Dic 1996Suncor, Inc.Coke drum deheading system
US562619123 Jun 19956 May 1997Petroleum Recovery InstituteOilfield in-situ combustion process
US56457143 May 19958 Jul 1997Bitman Resources Inc.Produce a bitumen froth and non-segregating tailings of solid material and sludge
US566754315 Abr 199416 Sep 1997Romico Hold A.V.V.Rotating particle separator with non-parallel separating ducts, and a separating unit
US572304217 Oct 19963 Mar 1998Bitmin Resources Inc.Oil sand extraction process
US57408342 Ago 199621 Abr 1998Exxon Research And Engineering CompanyReverse angle integrally counter-weighted trickle valve
US579808710 Dic 199625 Ago 1998Kansai Electric Power Co., Inc.Complete combusting the pure hydrogen sulfide separated from dehydrogenation, desulfurization of raw fuel
US582075017 Ene 199713 Oct 1998Exxon Research And Engineering CompanyReducing total acid number of whole crude or crude fraction feed; pressurization; removing water vapor and gaseous reaction products
US587659218 May 19952 Mar 1999Alberta Energy Co., Ltd.Using hydrocarbon solvent
US589776929 Ago 199727 Abr 1999Exxon Research And Engineering Co.Process for selectively removing lower molecular weight naphthenic acids from acidic crudes
US591024229 Ago 19978 Jun 1999Exxon Research And Engineering CompanyContacting with a hydrotreating catalyst in the presence of hydrogen treat gas containing hydrogen sulfide
US59285013 Feb 199827 Jul 1999Texaco Inc.Catalytic hydrotreatment using catalyst comprising polyphosphate-treated carbon support loaded with group viii and group vib metal to reduce total acid number and increase specific gravity of crude oil without deposit formation
US596182127 Mar 19985 Oct 1999Exxon Research And Engineering CoRemoval of naphthenic acids in crude oils and distillates
US6007709 *31 Dic 199728 Dic 1999Bhp Minerals International Inc.Counter-current decantation process for the extraction of bitumen from bitumen froth generated from a tar sands using a water process
US6391190 *4 Mar 199921 May 2002Aec Oil Sands, L.P.Mechanical deaeration of bituminous froth
US6800116 *18 Jul 20025 Oct 2004Suncor Energy Inc.Static deaeration conditioner for processing of bitumen froth
Otras citas
Referencia
1Alberta Oil History, An Interview with Roger Butler, vol. 2 Issue 2, pp. 33-35.
2Al-Shamali and Greaves, "In Situ Combustion (ISC) Processes: Enhances Oil Recovery Using Horizontal Wells", School of Chemical Engineering, University of Bath, UK, Trans IChemE, vol. 71, Part A, May 1993, pp. 345-346.
3Bagci and Shamsul, "A Comparison of Dry Forward Combusion with Diverse Well Configurations in a 3-D Physical Model Using Medium and Low Gravity Crudes", Middle East Technical University (10 pages).
4Bratsch and lagowski, On the Existence of Na in Liquid Ammonia, 1984 American Chemical Society, 1086-1089 pp. 1086-1089.
5Collison, "Hot About Thai: A Calgary company researches a step-change in bitumen recovery technology", Oilweek Mar. 1, 2004, pp. 42-46.
6District 5 CIM Conference, Presentation slides "Identification and Treatment of Weathered Ores at Suncor's Steepbank Mine", Jun. 14, 2001, Alberta, Canada.
7European Commission, European Symposium on Heavy Oil Technologies in a Wider Europe, A Therme Programme Action Berlin, Jun. 7 & 8, 1994, Greaves, Wang and Al-Shamali, "Insitu Combustion (ISC) Processes: 3D Studies of Vertical and Horizontal Wells", IOR Research Group, School of Chemical Engineering, University of Bath, UK.
8Eva Mondt "Compact Centrifugal Separator of Dispersed Phases" Proefschrift.
9Fenske, McCormick, Lawroski, and Geier, "Extraction of Petroleum Fractions by Ammonia Solvents", E.I.Ch.E. Journal, vol. 1. No. 3. pp. 335-341.
10Greaves, Tuwil and Bagci, "Horizontal Producer Wells in in Situ Combustion (ISC) Process", The Journal of Canadian Petroleum Technology, Apr. 1993, vol. 32, No. 4, pp. 58-67.
11IEO 1997 World Oil Markets "The World Oil Market" pp. 1-19.
12Industry Statistics "Monthly Petroleum Facts at a Glance" Jan. 2002 pp. 1-2.
13Jones and Goldstein "The SkyMine Process", Skyonic Corporation Sep. 20, 2005.
14Keller, Noble and Caffey "A Unique, Reagent-Based, Separation Method for Tar Sands and Environmentall Clean Ups" Presented to AIChE 2001 Annual Meeting Nov. 6, 2001 Reno, Nevada.
15Krebs' Engineers, Krebs D-Series gMAX DeSanders for Oil and Gas, Bulletin 11-203WEL.
16Lagowski, Liquid Ammonia-A Unique Solvent, Chemistry vol. 41, No. 4, pp. 10-15.
17Lemley, Roberts, Plowman and Lagowski, Liquid Ammonia Solutions. X. A Raman Study of Interactions in the Liquid State, The Journal of Physical Chemistry vol. 77 No. 18, 1973 pp. 2185-2191.
18Miner's Toolbox, Mine Backfill Engineering, 2000-2005.
19Minespace 2001, Presentation slides "Identification ad Treatment of Weathered Ores at Suncor's Steepbank Mine", May 2, 2001, Quebec City, Canada.
20Natural Resources Canada, Treatment of Bitumen Froth and Slop Oil Tailings, National Energy Board, Canada's Oil Sands: A Supply and Market Outlook to 2015, An Energy Market Assessment Oct. 2000.
21New Logic Research, Using V SEP to Treat Desalter Effluent, Case Study Copyright 2003 9 pages.
22Rimmer, Gregoli and Yildlrim, "Hydrocyclone-based Process for Rejecting Solids from Oil Sands at the Mine Site While Retaining Bitumen for Transportation to a Processing Plant"; Suncor Extraction 3rd fl pp. 93-100, Paper delivered on Monday Apr. 5, 1993 at a conference in Alberta, Canada entitled "Oil Sands-Our Petroleum Future".
23Schramm et al. "Some Observations on the Aging Phenomenon in the Hot Water Processing of Athabasca Oil Sands. Part 1-The Nature of the Phenomenom", AOSTRA J. Res., 3 (1987) 195-214.
24Schramm et al. "Some Observations on the Aging Phenomenon in the Hot Water Processing of Athabasca Oil Sands. Part 2-The Mechanism of Aging", AOSTRA J. Res., 3 (1987) 215-224.
25Schramm et al. "Two Classes of Anionic Surfactants and Their Significance in Hot Water Processing of Oil Sands", Can. J. Chem. Eng., 65 (1987) 799-811.
26Schramm, Smith and Stone "The Influence of Natural Surfactant Concentration on the Hot Water Process for Recovering Bitumen from the Athabasca Oil Sands" AOSTRA Journal of Research, vol. 1, 1984 pp. 5-13.
27The Fine Tailings Fundamentals Consortium "Advances in Oil Sands Tailings Research" ISBN 0-7732-1691-X Published by Alberta Department of Energy Jun. 1995.
28Wallace et al. "A Physical Chemical Explanation for Deterioration in the Hot Water Processability of Athabasca Oil Sand Due to Aging", Fuel Sci. Technol. Int., 7 (1989) 699-725.
Citada por
Patente citante Fecha de presentación Fecha de publicación Solicitante Título
US767739725 Jul 200516 Mar 2010Suncor Energy Inc.Sizing roller screen ore processing apparatus
US813667223 Dic 200920 Mar 2012Suncor Energy, Inc.Sizing roller screen ore processing apparatus
US832812618 Sep 200911 Dic 2012Suncor Energy, Inc.Method and apparatus for processing an ore feed
US835729119 Dic 200822 Ene 2013Exxonmobil Upstream Research CompanyUpgrading bitumen in a paraffinic froth treatment process
US862232624 Oct 20117 Ene 2014Suncor Energy, Inc.Method and apparatus for processing an ore feed
US8685210 *28 Mar 20111 Abr 2014Suncor Energy Inc.Bituminous froth inline steam injection processing
US20110174592 *28 Mar 201121 Jul 2011Suncor Energy Inc.Bituminous froth inline steam injection processing
Clasificaciones
Clasificación de EE.UU.196/14.52, 366/101, 95/262, 208/391, 209/12.1, 208/390
Clasificación internacionalB01D11/00, C10G1/02, B01F13/02, B03B9/02, C10C3/00, C10G1/04
Clasificación cooperativaC10G2300/807, C10G1/02
Clasificación europeaC10G1/02
Eventos legales
FechaCódigoEventoDescripción
28 Dic 2012FPAYFee payment
Year of fee payment: 4
16 Abr 2004ASAssignment
Owner name: SUNCOR ENERGY INC., CANADA
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:GASTON, LES;MADGE, DONALD NORMAN;STRAND, WILLIAM LESTER;AND OTHERS;REEL/FRAME:015224/0523;SIGNING DATES FROM 20040116 TO 20040121